Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.12.2024 - 01:26
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6407/9-3

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6407/9-3
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    APPRAISAL
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    RE-CLASS TO DEV
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORWEGIAN SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6407/9-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    84 - 140 SP. 529
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    A/S Norske Shell
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    463-L
    Drilling facility
    Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    87
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    03.05.1985
    Completed date
    Exploration wellbores from moveable facilities:
    For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    28.07.1985
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    28.07.1987
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    28.06.2007
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    APPRAISAL
    Reclassified to wellbore
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    OIL
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    NO
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    LATE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    ROGN FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    279.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1868.0
    Final vertical depth (TVD) [m RKB]
    Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).
    1868.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    63
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    EARLY JURASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 19' 48.94'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 46' 30.91'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7134564.04
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    440802.82
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    469

  • Wellbore history
    General
    Appraisal well 6407/9-3 was the third well on the antiform structure of the Draugen Field in the Haltenbanken area. It was placed on the crestal part of the structure, some four kilometres south of the discovery well. The main objectives of the well were to evaluate the lateral continuity and quality of the reservoir; to establish the velocity trend in a North-South direction; to improve the volumetric estimate; and to evaluate the oil deliverability.
    Operations and results
    Appraisal well 6407/9-3 was spudded with the semi-submersible installation Borgny Dolphin 3 may 1985 and drilled to TD at 1868 m in the Early Jurassic Tilje Formation. Drilling proceeded without serious problems, except for the sections trough glacial deposits were boulders caused minor problems. After setting 13 3/8" casing at 1601 m the RKB datum was shifted one m to 26 m above MSL. Operations were interrupted for nearly 17 days from 13 June 1985 by a crew strike. Although amplitude anomalies indicated gas charged sands, no shallow gas was encountered. The well was drilled with seawater and bentonite down to 781 m, with KCl mud from 781 m to 1617 m, and with chalk mud from 1617 m to TD.
    The top of the Rogn Formation was penetrated at 1630 m (1604 m SS) and the reservoir was oil bearing down to an oil-water contact at 1664 m (1638 m SS), which is in line with the OWC observed in the other Draugen wells. The contact in this well was interpreted in the transition between the good sands and the basal shales and was for that reason not very clear. The average hydrocarbon saturation was calculated as 82% over the 34 m oil column. Average porosity was 31% in this interval, of which 16.7 m had a porosity above 32.5%. Prior to testing an FMT survey was carried out: the reservoir pressure measured was hydrostatic, 2395 psia at datum (1630 m SS). The Garn Formation was penetrated from 1685 m to 1770 m and was water wet. Oil and oil shows were recorded in the Rogn formation only, not in any other porous section in the well. Nine conventional cores were cut in the interval 1620.5 m to 1679.8 m. One FMT oil sample was taken at 1637.5 m.
    The oil appraisal well 6407/9-3 was suspended 28 July 1985 as a possible producer. In 1993 it was re-entered reclassified to development well (producer).
    Testing
    One DST test was performed. The oil column was perforated from 1630.5 m to 1642.5 m (1606.5 to 1618.5 m SS). The interval was gravel packed and flow rates up to 2496 Sm3/day (15700 stb/d) were achieved during the clean up. A multirate test incorporating 4 flow periods with a total flow duration of 36 hrs and a 24 hrs pressure build-up survey was carried out. The evaluation showed an average permeability of 5.7 Darcy over 36 m. Skins calculated ranged from 24 to 29. Observed productivity indices after gravel packing varied from 147 to 166 stb/d/psi. The calculated ideal PI is 660 stb/d/psi. With flow rate at 2496 Sm3/day on a 2 x 128/64" choke, GOR was 18 - 27 Sm3/Sm3 (100 - 150 scf/stb), oil gravity was 40 deg API, CO2 content was 0.75%, and H2S was not detectable.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    390.00
    1869.00

  • Cores at the Norwegian Offshore Directorate
    Cores at the Norwegian Offshore Directorate
    Core sample number
    Core sample - top depth
    Core sample - bottom depth
    Core sample depth - uom
    1
    1620.5
    1621.2
    [m ]
    2
    1621.8
    1623.3
    [m ]
    5
    1627.5
    1628.0
    [m ]
    6
    1634.0
    1650.9
    [m ]
    7
    1652.0
    1667.0
    [m ]
    8
    1667.0
    1672.0
    [m ]
    9
    1673.0
    1679.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    46.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1620-1621m
    Core photo at depth: 1621-1623m
    Core photo at depth: 1627-1628m
    Core photo at depth: 1634-1639m
    Core photo at depth: 1639-1644m
    1620-1621m
    1621-1623m
    1627-1628m
    1634-1639m
    1639-1644m
    Core photo at depth: 1644-1649m
    Core photo at depth: 1649-1650m
    Core photo at depth: 1652-1657m
    Core photo at depth: 1657-1662m
    Core photo at depth: 1662-1667m
    1644-1649m
    1649-1650m
    1652-1657m
    1657-1662m
    1662-1667m
    Core photo at depth: 1667-1672m
    Core photo at depth: 1673-1678m
    Core photo at depth: 1678-1679m
    Core photo at depth:  
    Core photo at depth:  
    1667-1672m
    1673-1678m
    1678-1679m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1640.2
    [m]
    C
    RRI
    1667.6
    [m]
    C
    RRI
    1668.2
    [m]
    C
    RRI

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    TEST1E
    1631.00
    1643.00
    20.07.1985 - 01:30
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.42

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.33

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    pdf
    5.94
    pdf
    0.88

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    1631
    1643
    50.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    2500
    49000
    0.825
    0.810
    21

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CDL CNL GR
    350
    778
    CDL CNL GR
    550
    1596
    CDL CNL SPL
    1450
    1865
    CORGUN
    770
    1601
    CORGUN
    1601
    1868
    DIFL ACL SP GR
    266
    779
    DIFL ACL SP GR
    702
    1605
    DIFL ACL SP GR
    1504
    1867
    DIPLOG
    1595
    1862
    DLL MLL GR
    1580
    1864
    FMT
    1630
    1847
    VELOCITY
    401
    1863

  • Casing and leak–off tests
    Casing and leak–off tests
    Casing type
    Casing diam.
    [inch]
    Casing depth
    [m]
    Hole diam.
    [inch]
    Hole depth
    [m]
    LOT/FIT mud eqv.
    [g/cm3]
    Formation test type
    CONDUCTOR
    30
    376.5
    36
    383.0
    0.00
    LOT
    SURF.COND.
    20
    770.0
    26
    780.0
    1.46
    LOT
    INTERM.
    13 3/8
    1601.0
    17 1/2
    1617.0
    1.66
    LOT
    INTERM.
    9 5/8
    1843.0
    12 1/4
    1868.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    314
    1.03
    WATER BASED
    06.05.1985
    383
    1.03
    WATER BASED
    06.05.1985
    385
    1.03
    WATER BASED
    07.05.1985
    385
    1.03
    10.0
    36.0
    WATER BASED
    09.05.1985
    385
    1.03
    10.0
    36.0
    WATER BASED
    09.05.1985
    418
    1.25
    WATER BASED
    29.07.1985
    750
    1.10
    8.0
    48.0
    WATER BASED
    13.05.1985
    760
    1.08
    6.0
    29.0
    WATER BASED
    09.05.1985
    780
    1.09
    6.0
    60.0
    WATER BASED
    10.05.1985
    780
    1.11
    7.0
    49.0
    WATER BASED
    13.05.1985
    780
    1.11
    10.0
    30.0
    WATER BASED
    13.05.1985
    780
    1.11
    10.0
    30.0
    WATER BASED
    13.05.1985
    780
    1.11
    11.0
    38.0
    WATER BASED
    21.05.1985
    780
    1.11
    11.0
    38.0
    WATER BASED
    21.05.1985
    780
    1.11
    7.0
    49.0
    WATER BASED
    13.05.1985
    970
    1.30
    25.0
    29.0
    WATER BASED
    21.05.1985
    1250
    1.15
    WATER BASED
    29.07.1985
    1274
    1.32
    23.0
    21.0
    WATER BASED
    21.05.1985
    1512
    1.34
    23.0
    19.0
    WATER BASED
    21.05.1985
    1512
    1.34
    24.0
    22.0
    WATER BASED
    21.05.1985
    1512
    1.34
    24.0
    22.0
    WATER BASED
    21.05.1985
    1570
    1.15
    WATER BASED
    26.07.1985
    1612
    1.22
    18.0
    28.0
    WATER BASED
    31.05.1985
    1617
    1.38
    25.0
    23.0
    WATER BASED
    21.05.1985
    1617
    1.38
    25.0
    24.0
    WATER BASED
    22.05.1985
    1617
    1.38
    25.0
    WATER BASED
    23.05.1985
    1617
    1.38
    25.0
    24.0
    WATER BASED
    22.05.1985
    1617
    1.38
    25.0
    WATER BASED
    23.05.1985
    1620
    1.24
    13.0
    21.0
    WATER BASED
    29.05.1985
    1627
    1.22
    19.0
    29.0
    WATER BASED
    03.06.1985
    1633
    1.21
    19.0
    29.0
    WATER BASED
    03.06.1985
    1649
    1.22
    18.0
    27.0
    WATER BASED
    12.06.1985
    1665
    1.22
    21.0
    28.0
    WATER BASED
    14.06.1985
    1665
    1.22
    21.0
    28.0
    WATER BASED
    17.06.1985
    1665
    1.22
    21.0
    28.0
    WATER BASED
    17.06.1985
    1666
    1.15
    WATER BASED
    16.07.1985
    1666
    1.15
    WATER BASED
    22.07.1985
    1666
    1.15
    WATER BASED
    15.07.1985
    1666
    1.15
    WATER BASED
    22.07.1985
    1666
    1.15
    WATER BASED
    10.07.1985
    1666
    1.15
    WATER BASED
    12.07.1985
    1666
    1.15
    WATER BASED
    15.07.1985
    1666
    1.15
    WATER BASED
    18.07.1985
    1666
    1.15
    WATER BASED
    19.07.1985
    1666
    1.15
    WATER BASED
    23.07.1985
    1666
    1.15
    WATER BASED
    25.07.1985
    1666
    1.15
    WATER BASED
    26.07.1985
    1666
    1.15
    WATER BASED
    09.07.1985
    1666
    1.15
    WATER BASED
    10.07.1985
    1666
    1.15
    WATER BASED
    12.07.1985
    1666
    1.15
    WATER BASED
    16.07.1985
    1666
    1.15
    WATER BASED
    18.07.1985
    1666
    1.15
    WATER BASED
    19.07.1985
    1666
    1.15
    WATER BASED
    23.07.1985
    1666
    1.15
    WATER BASED
    25.07.1985
    1666
    1.15
    WATER BASED
    26.07.1985
    1667
    1.23
    20.0
    30.0
    WATER BASED
    03.06.1985
    1673
    1.23
    21.0
    28.0
    WATER BASED
    13.06.1985
    1684
    1.23
    21.0
    30.0
    WATER BASED
    03.06.1985
    1818
    1.22
    19.0
    28.0
    WATER BASED
    10.06.1985
    1818
    1.22
    19.0
    29.0
    WATER BASED
    11.06.1985
    1818
    1.22
    19.0
    29.0
    WATER BASED
    11.06.1985
    1857
    1.21
    18.0
    27.0
    WATER BASED
    05.06.1985
    1868
    1.21
    18.0
    28.0
    WATER BASED
    06.06.1985
    1868
    1.21
    18.0
    27.0
    WATER BASED
    06.06.1985
    1868
    1.21
    18.0
    27.0
    WATER BASED
    07.06.1985
    1868
    1.21
    18.0
    29.0
    WATER BASED
    10.06.1985
    1868
    1.21
    18.0
    27.0
    WATER BASED
    07.06.1985
    1868
    1.21
    18.0
    29.0
    WATER BASED
    10.06.1985
    1868
    1.21
    18.0
    27.0
    WATER BASED
    06.06.1985

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    1640.30
    [m ]

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    PDF
    0.25